Analytical Inflow Performance Relationships

1999 ◽  
Vol 121 (1) ◽  
pp. 24-30
Author(s):  
M. L. Wiggins
Keyword(s):  
Multiphase Flow ◽  
Physical Nature ◽  
Oil Wells ◽  
Well Performance ◽  
Flow Conditions ◽  
Flow Equations ◽  
Petroleum Engineer ◽  
Single Well ◽  
Production Behavior ◽  
Inflow Performance

The performance of oil wells producing during boundary-dominated flow was investigated to develop a better understanding of multiphase flow and its effects on single well performance. This understanding can assist the petroleum engineer in predicting the pressure-production behavior of oil wells producing under boundary-dominated flow conditions. An analytical inflow performance relationship (IPR) was developed from the multiphase flow equations. This relationship is based on the physical nature of the multiphase flow system and contributes to a better understanding of the pressure-production behavior of an individual well. The analytical IPR was verified using simulator information and provides a method for the petroleum engineer to develop individual IPRs for each reservoir.

scholarly journals Development of Deep Transformer-Based Models for Long-Term Prediction of Transient Production of Oil Wells

2021 ◽  
Author(s):  
Ildar Radikovich Abdrakhmanov ◽  
Evgenii Alekseevich Kanin ◽  
Sergei Andreevich Boronin ◽  
Evgeny Vladimirovich Burnaev ◽  
Andrei Aleksandrovich Osiptsov
Keyword(s):  
Neural Networks ◽  
Transfer Learning ◽  
Multivariate Time Series ◽  
Operating Regime ◽  
Oil Wells ◽  
Well Testing ◽  
Novel Approach ◽  
Production History ◽  
Single Well ◽  
Bottomhole Pressure

Abstract We propose a novel approach to data-driven modeling of a transient production of oil wells. We apply the transformer-based neural networks trained on the multivariate time series composed of various parameters of oil wells measured during their exploitation. By tuning the machine learning models for a single well (ignoring the effect of neighboring wells) on the open-source field datasets, we demonstrate that transformer outperforms recurrent neural networks with LSTM/GRU cells in the forecasting of the bottomhole pressure dynamics. We apply the transfer learning procedure to the transformer-based surrogate model, which includes the initial training on the dataset from a certain well and additional tuning of the model's weights on the dataset from a target well. Transfer learning approach helps to improve the prediction capability of the model. Next, we generalize the single-well model based on the transformer architecture for multiple wells to simulate complex transient oilfield-level patterns. In other words, we create the global model which deals with the dataset, comprised of the production history from multiple wells, and allows for capturing the well interference resulting in more accurate prediction of the bottomhole pressure or flow rate evolutions for each well under consideration. The developed instruments for a single-well and oilfield-scale modelling can be used to optimize the production process by selecting the operating regime and submersible equipment to increase the hydrocarbon recovery. In addition, the models can be helpful to perform well-testing avoiding costly shut-in operations.

scholarly journals On the propagation of diel signals in river networks using analytic solutions of flow equations

2015 ◽  
Vol 12 (8) ◽  
pp. 8175-8220 ◽  
Author(s):  
M. Fonley ◽  
R. Mantilla ◽  
S. J. Small ◽  
R. Curtu
Keyword(s):  
Analytic Solutions ◽  
River Network ◽  
Low Flow ◽  
River Networks ◽  
Signal Delay ◽  
Flow Conditions ◽  
Flow Equations ◽  
Linear Transport Equation ◽  
Daily Evapotranspiration ◽  
Self Similar

Abstract. Two hypotheses have been put forth to explain the magnitude and timing of diel streamflow oscillations during low flow conditions. The first suggests that delays between the peaks and troughs of streamflow and daily evapotranspiration are due to processes occurring in the soil as water moves toward the channels in the river network. The second posits that they are due to the propagation of the signal through the channels as water makes its way to the outlet of the basin. In this paper, we design and implement a theoretical experiment to test these hypotheses. We impose a baseflow signal entering the river network and use a linear transport equation to represent flow along the network. We develop analytic streamflow solutions for two cases: uniform and nonuniform velocities in space over all river links. We then use our analytic solutions to simulate streamflows along a self-similar river network for different flow velocities. Our results show that the amplitude and time delay of the streamflow solution are heavily influenced by transport in the river network. Moreover, our equations show that the geomorphology and topology of the river network play important roles in determining how amplitude and signal delay are reflected in streamflow signals. Finally, our results are consistent with empirical observations that delays are more significant as low flow decreases.

Gas Hydrate Sloughing as Observed and Quantified from Multiphase Flow Conditions

2018 ◽  
Vol 32 (3) ◽  
pp. 3399-3405 ◽  
Author(s):  
Erlend O. Straume ◽  
Celina Kakitani ◽  
Luis A. Simões Salomão ◽  
Rigoberto E. M. Morales ◽  
Amadeu K. Sum
Keyword(s):  
Multiphase Flow ◽  
Gas Hydrate ◽  
Flow Conditions

Production Forecast, Analysis and Simulation of Eagle Ford Shale Oil Wells

2015 ◽  
Author(s):  
Basel Alotaibi ◽  
David Schechter ◽  
Robert A. Wattenbarger
Keyword(s):  
Production Rate ◽  
Oil Production ◽  
Oil Wells ◽  
Unconventional Reservoirs ◽  
Production Data ◽  
Eagle Ford Shale ◽  
Production Forecast ◽  
Eagle Ford ◽  
Type Curves ◽  
Single Well

Abstract In previous works and published literature, production forecast and production decline of unconventional reservoirs were done on a single-well basis. The main objective of previous works was to estimate the ultimate recovery of wells or to forecast the decline of wells in order to estimate how many years a well could produce and what the abandonment rate was. Other studies targeted production data analysis to evaluate the completion (hydraulic fracturing) of shale wells. The purpose of this work is to generate field-wide production forecast of the Eagle Ford Shale (EFS). In this paper, we considered oil production of the EFS only. More than 6 thousand oil wells were put online in the EFS basin between 2008 and December 2013. The method started by generating type curves of producing wells to understand their performance. Based on the type curves, a program was prepared to forecast the oil production of EFS based on different drilling schedules; moreover drilling requirements can be calculated based on the desired production rate. In addition, analysis of daily production data from the basin was performed. Moreover, single-well simulations were done to compare results with the analyzed data. Findings of this study depended on the proposed drilling and developing scenario of EFS. The field showed potential of producing high oil production rate for a long period of time. The presented forecasted case gave and indications of the expected field-wide rate that can be witnessed in the near future in EFS. The method generated by this study is useful for predicting the performance of various unconventional reservoirs for both oil and gas. It can be used as a quick-look tool that can help if numerical reservoir simulations of the whole basin are not yet prepared. In conclusion, this tool can be used to prepare an optimized drilling schedule to reach the required rate of the whole basin.

Simultaneous Hydraulic Fracturing Improves Completion Efficiency and Lowers Costs Per Foot

2021 ◽  
Author(s):  
David Russell ◽  
Price Stark ◽  
Sean Owens ◽  
Awais Navaiz ◽  
Russell Lockman
Keyword(s):  
Hydraulic Fracturing ◽  
Oil And Gas ◽  
Horizontal Wells ◽  
Asset Returns ◽  
Gas Production ◽  
Well Performance ◽  
Additional Time ◽  
Oil And Gas Production ◽  
Single Well ◽  
Lateral Length

Abstract Reducing well costs in unconventional development while maintaining or improving production continues to be important to the success of operators. Generally, the primary drivers for oil and gas production are treatment fluid volume, proppant mass, and the number of stages or intervals along the well. Increasing these variables typically results in increased costs, causing additional time and complexity to complete these larger designs. Simultaneously completing two wells using the same volumes, rates, and number of stages as for any previous single well, allows for more lateral length or volume completed per day. This paper presents the necessary developments and outcomes of a completion technique utilizing a single hydraulic fracturing spread to simultaneously stimulate two or more horizontal wells. The goal of this technique is to increase operational efficiency, lower completion cost, and reduce the time from permitting a well to production of that well—without negatively impacting the primary drivers of well performance. To date this technique has been successfully performed in both the Bakken and Permian basins in more than 200 wells, proving its success can translate to other unconventional fields and operations. Ultimately, over 200 wells were successfully completed simultaneously, resulting in a 45% increase in completion speed and significant decrease in completion costs, while still maintaining equivalent well performance. This type of simultaneous completion scenario continues to be implemented and improved upon to improve asset returns.

Temporary Program Of Multiphase Flow Measurement To Provide Well Performance Data: Study Cases

2007 ◽  
Author(s):  
Jorge Alberto Arevalo Villagran ◽  
Teodulo Gutiérrez-Acosta ◽  
Jose Refugio Serrano-Lozano ◽  
Sergio Lopez-Ramirez ◽  
Horacio Ferreira
Keyword(s):  
Multiphase Flow ◽  
Flow Measurement ◽  
Performance Data ◽  
Well Performance
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